WO2004065917A2 - Puits multibranches a separation par gravite de fond - Google Patents

Puits multibranches a separation par gravite de fond Download PDF

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Publication number
WO2004065917A2
WO2004065917A2 PCT/US2003/033059 US0333059W WO2004065917A2 WO 2004065917 A2 WO2004065917 A2 WO 2004065917A2 US 0333059 W US0333059 W US 0333059W WO 2004065917 A2 WO2004065917 A2 WO 2004065917A2
Authority
WO
WIPO (PCT)
Prior art keywords
well
lateral
primary
water
hydrocarbons
Prior art date
Application number
PCT/US2003/033059
Other languages
English (en)
Other versions
WO2004065917A3 (fr
WO2004065917B1 (fr
Inventor
Thomas M. Snow
Original Assignee
Exxonmobil Upstream Research Company
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Exxonmobil Upstream Research Company filed Critical Exxonmobil Upstream Research Company
Priority to AU2003291645A priority Critical patent/AU2003291645A1/en
Publication of WO2004065917A2 publication Critical patent/WO2004065917A2/fr
Publication of WO2004065917A3 publication Critical patent/WO2004065917A3/fr
Publication of WO2004065917B1 publication Critical patent/WO2004065917B1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/14—Obtaining from a multiple-zone well
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/38—Arrangements for separating materials produced by the well in the well
    • E21B43/385—Arrangements for separating materials produced by the well in the well by reinjecting the separated materials into an earth formation in the same well

Definitions

  • This invention relates to a method for extending the productive life of a hydrocarbon well by reducing the percentage of water produced to the surface through the use of downhole gravity separation in conjunction with lateral wells.
  • the watercut affects the profitability of most wells, since the higher the watercut the lower the percentage of the production that consists of hydrocarbons, but the watercut also directly affects the operation costs. This is because in most wells, the disposal cost of handling the watercut includes the operating costs of bringing the water to the surface, separating the water from the hydrocarbons, and disposing of the separated water, often by re-injecting the water back into the subsurface. Therefore, decreasing the watercut of a well directly increases the value of the produced fluids and directly decreases the disposal costs.
  • One method of reducing the watercut of a well is to separate the water from the hydrocarbons downhole, rather than at the surface. Downhole separation increases the value of the fluids produced to the surface.
  • Downhole separation also facilitates downhole disposal of the separated water.
  • the separated water can be reinjected into the same production interval or into a different production interval. Separation can be achieved naturally, through gravity, or mechanically, for example through the use of a centrifuge.
  • a mechanical separator greatly complicates well maintenance. Injection zones are prone to plugging and where mechanical separation is employed, correction of the plugging first requires removal of the separator.
  • a multilateral well is a conventional well that has an additional "leg" or lateral well that is drilled firom a point in the original well.
  • the lateral well increases productivity by allowing additional intersection length along the productive interval without the cost and delay involved in re-drilling the upper part of the well. While multi-laterals enable multiple intersections within the same productive interval, multi-laterals also enable the intersection of different productive intervals within a reservoir. The use of multi-laterals increases the potential production of a well and can enable alternate water disposal locations, in the event that reinjection to the same productive interval is undesired.
  • One embodiment of the present invention provides a method for recovering hydrocarbons from a subterranean production interval while reducing the percentage of water produced, comprising: (a) drilling a lateral well from a primary well, (b) deploying a submersible pump to a position in the primary well below the intersection with the lateral well, (c) allowing hydrocarbons and water to separate by gravity, and (d) pumping water into the production interval, at a rate sufficient to allow gravity separation of the water and hydrocarbons in the area above the submersible pump, while producing the hydrocarbons to the surface.
  • Another embodiment of the present invention provides a method for recovering hydrocarbons from a subterranean production interval while reducing the percentage of water produced, comprising: (a) drilling a lateral well from an existing primary well, wherein the lateral well terminates in the same production interval as the primary well; (b) installing tubing in the primary well, wherein the tubing includes means to allow an inflow of fluid into the tubing from the well; (c) deploying a variable speed submersible pump to a position in the tubing below the intersection with the lateral well; and (d) pumping water into the production interval, through the primary well, at a rate sufficient to allow the gravity separation of the water and hydrocarbons in the area above the variable speed submersible pump.
  • the present invention provides a well completion system comprising: (a) a primary well extending from the surface to a subterranean production interval; (b) a lateral well extending from the primary well to the subterranean production interval; (c) a tubing string extending from the surface to a location within the lateral well below the intersection with the primary well, wherein the tubing includes means to allow inflow of fluid; and (d) a submersible pump located within the tubing, below the intersection of the lateral well with the primary well, wherein the pump operates at a rate sufficient to allow the gravity separation of the water and hydrocarbons in the area above the pump.
  • FIG. 1 is an elevation view of an embodiment of the invention where a single lateral well intersects the primary well.
  • FIG. 2 is an elevation view of an embodiment of the invention where two lateral wells intersect the primary well.
  • This invention requires that a lateral well be drilled from an existing primary well.
  • a submersible pump is positioned in the primary well, below its intersection with the lateral well.
  • the fluids above the submersible pump are allowed to separate through gravity into water and hydrocarbons.
  • the submersible pump is able to be run at various speeds and the speed at which the submersible pump injects the separated water into the production interval intersected by the primary well is controlled so as to continue to allow the gravity separation of the produced fluids.
  • the submersible pump is preferably electric, however, suitable pumps also include cavity pumps, rod pumps, or any other pumping device suited to the present invention.
  • This invention can be used to enable downhole separation and injection of water into the production interval of the original primary well or into another production interval which may be connected or unconnected to the production interval being produced.
  • One or more lateral wells can be utilized.
  • the pump can also be located in a lateral well instead of in the primary well.
  • a tubing string can be run from the surface to a location in the primary well below the intersection with the lateral well.
  • the tubing would transport the hydrocarbons to the surface and the water to the submersible pump. Therefore, the tubing in the area where the fluids are separating through gravity would have to allow the influx of fluids from the well.
  • the invention may utilize tubing perforated in the area above the submersible pump, however methods of allowing the necessary inflow of fluids into the tubing are not limited to perforations.
  • the present invention may be particularly useful in moderate flow rate wells, for example 500-5000 barrels of fluid per day.
  • Most multi-laterals are planned for very high rate wells - up to 50,000 barrels of fluid per day. These high rate wells will have substantially less time for the fluids to separate naturally, so adequate gravity separation is much less likely.
  • the large revenue associated with these high rate wells has led to focusing on more expensive solutions.
  • These low rate wells in the 200 barrel per day range or less) tend to be shallow, and relatively inexpensive to drill. Therefore, there is little incentive to apply multi-lateral technology to save drilling costs.
  • FIG. 1 illustrates a primary well 1 with one lateral well 2 drilled from a point within the primary well 1 to a production interval 6.
  • the primary well 1 intersects an original production interval 5.
  • tubing 3 is inserted into the primary well 1 extending to a point below its intersection 10 with the lateral well 2.
  • a lower annular plug 8 prevents fluid communication between the intersection 10 and the original production interval 5 except through the tubing 3.
  • a upper annular plug or packer 9 prevents fluid communication between the intersection 10 and the surface production facilities (not shown) except through the tubing 3.
  • perforations 7 in the tubing 3 allow the influx of production fluids from the area above the intersection 10 of the primary well 1 and the lateral well 2.
  • An electric submersible pump 4 has been deployed within the tubing 3 to a position below the perforations 7.
  • the electric submersible pump 4 is operated at a speed that enables the injection of water into the original production interval 5, by allowing the gravity separation of the produced fluids in the area above the electric submersible pump 4.
  • FIG. 2 illustrates another possible embodiment of the invention that includes the addition of a second lateral well 12.
  • the second lateral well 12 intersects the primary well 1 between upper annular plug 9 and lower annular plug 8.
  • the second lateral well 12 can intersect the same production interval as the primary well 1, or the same production interval intersected by the lateral well 2, or as in this example, it may intersect with an unconnected production interval 13.
  • additional lateral wells may be drilled from the primary well 1 in such a way as to allow water injection into the original production interval 5.
  • This invention will allow the disposal of produced water downhole, minimizing operating expense and allowing more oil to be economically produced. It represents an improvement over gravity separation in a conventional well because the water can be injected at a location some distance away from the producing well.
  • the well completion system may be constructed with the following steps: 1. drill and complete a primary well, producing from it until it reaches an uneconomic watercut or amount of water; 2. create a lateral well by adding a second "leg" to the original hole; 3. complete the lateral well; 4. remove the sidetracking equipment and "recover” the original completion; 5. run tubing from surface to the original completion with packers; 6. place a plug in the original well, and begin producing from the lateral well; 7. after the well is producing a significant amount of water, pull the plug on the original completion, and deploy an electric submersible pump on coiled tubing; and 8. use the variable speed on the pump to control the rate of water injection into the original primary well.
  • This design allows water to favorably separate by gravity from the oil while flowing up the lateral, and in the area of the junction.
  • the quality of separation will be dependent on flow rates, oil and water density, and emulsion characteristics of the fluids. It is anticipated that some water will be produced to the surface with the oil, and that a trace amount of oil will be injected with the water.
  • the preferred operating conditions will be different for each application.
  • This method is preferable to other downhole separation methods because it is mechanically simple (minimal moving parts), and it provides easy access to the main wellbore for re-entry if the injection completion plugs.
  • the invention will initially be deployed as described above.
  • An existing primary well that will no longer produce at economic rates may be used to create the multi-lateral well.
  • the primary well is a conventional well that makes a high watercut. It will be sidetracked and a horizontal lateral will be drilled and completed. Then the original completion will be recovered using standard multi-lateral techniques, and a plug will be installed in this completion. Oil and water will be produced from the lateral until such time as the well is making a significant and stable watercut. Then the plug in the lower zone will be pulled, and a pump may be deployed on coiled tubing. Using a variable speed controller on the pump will allow favorable injection of water, with a minimal loss of oil.
  • the oil reservoir which is produced by the horizontal lateral, has weak water support, and requires injection to maintain pressure.
  • an injection well and a production well are obtained. Additionally, the surface handling of the fluids is substantially reduced. Since the water is returning to the same reservoir where the production is coming from, a small amount of oil carried down with the water will not be of concern. Also, since the water production and injection are in the same reservoir, the waters will be compatible and scale precipitation should not occur.
  • This invention may be applied with multiple types of hardware schemes, and with many different pump designs.
  • a cement junction at the multi-lateral point (known in the industry as a level 4 multi-lateral) is typical, but any type of junction that is appropriate for the area could be applied.
  • cavity pumps or rod pumps and other devices known in the art may be used to pump the water or produce the oil, rather than an electric submersible pump and gas lift.
  • the degree of separation is dependent on flow rate, tubing/casing size, and fluid properties.
  • Current technology makes the quality of the separation difficult to predict.
  • data collected from horizontal wells suggest that the oil and water are already reasonably well separated in the horizontal section.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Structures Of Non-Positive Displacement Pumps (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention porte sur un procédé servant à récupérer des hydrocarbures d'un intervalle de production souterrain tout en réduisant le pourcentage d'eau produite. Un puits latéral est foré à partir d'un puits primaire existant. Une pompe submersible est mise en place à un certain endroit dans le puits primaire, au-dessous de l'intersection avec le puits latéral. La pompe injecte l'eau séparée dans l'intervalle de production par le puits primaire à un débit suffisant pour permettre une séparation par gravité favorable des hydrocarbures et de l'eau dans la zone située au-dessus de la pompe submersible. Les pompes submersibles adaptées comprennent les pompes submersibles électriques, les pompes à cavité et les pompes à tiges. Un ou plusieurs puits latéraux peuvent être utilisés. Les puits latéraux peuvent croiser le même intervalle de production que le puits primaire ou peuvent croiser un intervalle de production non raccordé.
PCT/US2003/033059 2003-01-14 2003-10-17 Puits multibranches a separation par gravite de fond WO2004065917A2 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU2003291645A AU2003291645A1 (en) 2003-01-14 2003-10-17 Multi-lateral well with downhole gravity separation

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US10/341,946 2003-01-14
US10/341,946 US6923259B2 (en) 2003-01-14 2003-01-14 Multi-lateral well with downhole gravity separation

Publications (3)

Publication Number Publication Date
WO2004065917A2 true WO2004065917A2 (fr) 2004-08-05
WO2004065917A3 WO2004065917A3 (fr) 2004-10-28
WO2004065917B1 WO2004065917B1 (fr) 2005-02-17

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Country Status (4)

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US (1) US6923259B2 (fr)
AU (1) AU2003291645A1 (fr)
MY (1) MY137190A (fr)
WO (1) WO2004065917A2 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2484525A (en) * 2010-10-14 2012-04-18 Apec Ltd Gravity separation of water from production fluid in a wellbore
WO2016018223A1 (fr) * 2014-07-28 2016-02-04 Halliburton Energy Services Inc. Outillage de complétion transporté par jonction et opérations

Families Citing this family (12)

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US20050087336A1 (en) 2003-10-24 2005-04-28 Surjaatmadja Jim B. Orbital downhole separator
US7429332B2 (en) * 2004-06-30 2008-09-30 Halliburton Energy Services, Inc. Separating constituents of a fluid mixture
US7370701B2 (en) * 2004-06-30 2008-05-13 Halliburton Energy Services, Inc. Wellbore completion design to naturally separate water and solids from oil and gas
US7462274B2 (en) * 2004-07-01 2008-12-09 Halliburton Energy Services, Inc. Fluid separator with smart surface
US7823635B2 (en) * 2004-08-23 2010-11-02 Halliburton Energy Services, Inc. Downhole oil and water separator and method
US20080173440A1 (en) * 2004-10-22 2008-07-24 Petroleo Brasileiro S.A. - Petrobras System for injecting water, collected from a subterranean aquifer, into an oil reservoir
GB2443190B (en) * 2006-09-19 2009-02-18 Schlumberger Holdings System and method for downhole sampling or sensing of clean samples of component fluids of a multi-fluid mixture
WO2010016767A2 (fr) * 2008-08-08 2010-02-11 Ziebel As Système de drainage de réservoir souterrain
US8505627B2 (en) * 2009-10-05 2013-08-13 Schlumberger Technology Corporation Downhole separation and reinjection
US10400592B2 (en) 2013-05-10 2019-09-03 Baker Hughes, A Ge Company, Llc Methodology for presenting dumpflood data
US9598943B2 (en) * 2013-11-15 2017-03-21 Ge Oil & Gas Esp, Inc. Distributed lift systems for oil and gas extraction
US9677388B2 (en) 2014-05-29 2017-06-13 Baker Hughes Incorporated Multilateral sand management system and method

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GB2326895A (en) * 1997-07-03 1999-01-06 Schlumberger Ltd Separation of oil-well fluid mixtures by gravity
CA2253685A1 (fr) * 1997-11-07 1999-05-07 Baker Hughes Incorporated Systeme de pompage et de separation des hydrocarbures fluides, et appareil connexe
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Cited By (7)

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Publication number Priority date Publication date Assignee Title
GB2484525A (en) * 2010-10-14 2012-04-18 Apec Ltd Gravity separation of water from production fluid in a wellbore
WO2012049511A3 (fr) * 2010-10-14 2013-06-20 Apec Ltd Séparateur d'eau gravitaire de puits de forage
WO2016018223A1 (fr) * 2014-07-28 2016-02-04 Halliburton Energy Services Inc. Outillage de complétion transporté par jonction et opérations
GB2543200A (en) * 2014-07-28 2017-04-12 Halliburton Energy Services Inc Junction-conveyed completion tooling and operations
US9822612B2 (en) 2014-07-28 2017-11-21 Halliburton Energy Services, Inc. Junction-conveyed completion tooling and operations
US10240434B2 (en) 2014-07-28 2019-03-26 Halliburton Energy Services Inc. Junction-conveyed completion tooling and operations
GB2543200B (en) * 2014-07-28 2021-03-17 Halliburton Energy Services Inc Junction-conveyed completion tooling and operations

Also Published As

Publication number Publication date
US20040134654A1 (en) 2004-07-15
US6923259B2 (en) 2005-08-02
AU2003291645A8 (en) 2004-08-13
MY137190A (en) 2009-01-30
WO2004065917A3 (fr) 2004-10-28
AU2003291645A1 (en) 2004-08-13
WO2004065917B1 (fr) 2005-02-17

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